EP2419602A1 - Downhole draw-down pump and method - Google Patents
Downhole draw-down pump and methodInfo
- Publication number
- EP2419602A1 EP2419602A1 EP10764800A EP10764800A EP2419602A1 EP 2419602 A1 EP2419602 A1 EP 2419602A1 EP 10764800 A EP10764800 A EP 10764800A EP 10764800 A EP10764800 A EP 10764800A EP 2419602 A1 EP2419602 A1 EP 2419602A1
- Authority
- EP
- European Patent Office
- Prior art keywords
- well bore
- tubular member
- suction tube
- section
- annulus
- Prior art date
- Legal status (The legal status is an assumption and is not a legal conclusion. Google has not performed a legal analysis and makes no representation as to the accuracy of the status listed.)
- Withdrawn
Links
- 238000000034 method Methods 0.000 title claims abstract description 38
- 239000012530 fluid Substances 0.000 claims abstract description 114
- 239000007787 solid Substances 0.000 claims abstract description 49
- 229930195733 hydrocarbon Natural products 0.000 claims abstract description 27
- 150000002430 hydrocarbons Chemical class 0.000 claims abstract description 27
- VNWKTOKETHGBQD-UHFFFAOYSA-N methane Chemical group C VNWKTOKETHGBQD-UHFFFAOYSA-N 0.000 claims description 90
- 239000003345 natural gas Substances 0.000 claims description 28
- 239000007789 gas Substances 0.000 claims description 26
- 238000002347 injection Methods 0.000 claims description 25
- 239000007924 injection Substances 0.000 claims description 25
- 239000004215 Carbon black (E152) Substances 0.000 claims description 23
- 239000003381 stabilizer Substances 0.000 claims description 11
- 239000000203 mixture Substances 0.000 claims description 6
- 239000007788 liquid Substances 0.000 claims description 5
- 238000007599 discharging Methods 0.000 claims description 4
- 230000005465 channeling Effects 0.000 claims description 2
- 230000000087 stabilizing effect Effects 0.000 claims description 2
- 238000004519 manufacturing process Methods 0.000 description 24
- XLYOFNOQVPJJNP-UHFFFAOYSA-N water Substances O XLYOFNOQVPJJNP-UHFFFAOYSA-N 0.000 description 12
- 239000003245 coal Substances 0.000 description 9
- 230000015572 biosynthetic process Effects 0.000 description 8
- 230000000694 effects Effects 0.000 description 5
- 238000011065 in-situ storage Methods 0.000 description 4
- 229910052500 inorganic mineral Inorganic materials 0.000 description 3
- 239000011707 mineral Substances 0.000 description 3
- 239000003570 air Substances 0.000 description 2
- 238000010276 construction Methods 0.000 description 2
- 230000003247 decreasing effect Effects 0.000 description 2
- 238000013461 design Methods 0.000 description 2
- 230000002706 hydrostatic effect Effects 0.000 description 2
- 238000012423 maintenance Methods 0.000 description 2
- 230000014759 maintenance of location Effects 0.000 description 2
- 230000035699 permeability Effects 0.000 description 2
- 239000011435 rock Substances 0.000 description 2
- 238000000926 separation method Methods 0.000 description 2
- 238000003756 stirring Methods 0.000 description 2
- 238000003860 storage Methods 0.000 description 2
- 238000003466 welding Methods 0.000 description 2
- 240000008100 Brassica rapa Species 0.000 description 1
- 230000009286 beneficial effect Effects 0.000 description 1
- 230000002950 deficient Effects 0.000 description 1
- 230000001419 dependent effect Effects 0.000 description 1
- 238000005553 drilling Methods 0.000 description 1
- 239000002609 medium Substances 0.000 description 1
- -1 methane gas Chemical compound 0.000 description 1
- 238000012986 modification Methods 0.000 description 1
- 230000004048 modification Effects 0.000 description 1
- 238000012552 review Methods 0.000 description 1
- 238000004513 sizing Methods 0.000 description 1
Classifications
-
- E—FIXED CONSTRUCTIONS
- E21—EARTH DRILLING; MINING
- E21B—EARTH DRILLING, e.g. DEEP DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B17/00—Drilling rods or pipes; Flexible drill strings; Kellies; Drill collars; Sucker rods; Cables; Casings; Tubings
- E21B17/18—Pipes provided with plural fluid passages
-
- E—FIXED CONSTRUCTIONS
- E21—EARTH DRILLING; MINING
- E21B—EARTH DRILLING, e.g. DEEP DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B43/00—Methods or apparatus for obtaining oil, gas, water, soluble or meltable materials or a slurry of minerals from wells
- E21B43/12—Methods or apparatus for controlling the flow of the obtained fluid to or in wells
- E21B43/121—Lifting well fluids
- E21B43/124—Adaptation of jet-pump systems
Definitions
- the present invention relates to a down-hole pump. More particularly, but not by way of limitation, this invention relates to a downhole draw-down pump used to withdraw fluid from a well bore and method.
- a well In the production of oil and gas, a well is drilled in order to intersect a hydrocarbon bearing deposit, as is well understood by those of ordinary skill in the art.
- the well may be of vertical, directional, or horizontal contour.
- natural gas including methane gas
- a well bore is drilled through the coai bed seam, and methane is produced via the well bore.
- Water encroachment can continue into the well bore, and again the water's hydrostatic pressure effect on the in-situ coal seam pressure can cause termination of gas production.
- the water in the sump and well bore should be withdrawn.
- rock, debris and formation fines can accumulate within this sump area and operarors find it beneficial to withdraw the rock and debris.
- the apparatus comprises a first tubular disposed within the well bore so that a well bore annulus is formed therein, and wherein the first tubular has a distal end and a proximal end.
- the apparatus further includes an annular nozzle operatively attached to the distal end of the first tubular, and wherein the annular nozzle comprises: an annular adapter: and, a suction tube that extends from the annular adapter into an inner portion of the first tubular.
- the suction tube may be threadedly attached to the annular adapter.
- the apparatus further comprises a second tubular concentrically disposed within the first tubular so that a micro annulus is formed therein, and wherein a first end of the second tubular is positioned adjacent the suction tube so that a restricted area is formed within an inner portion of the second tubular.
- the apparatus may further contain jet means, disposed within the first tubular, for delivering an injected medium from the micro annulus into the welt bore annulus. Also, the apparatus may include stabilizer means, disposed about the second tubular, for stabilizing the second tubular within the first tubular. The apparatus may further contain an inner tubing restriction sleeve disposed within the inner portion of the second tubular, and wherein the inner tubing restriction sleeve receives the suction tube.
- the apparatus may include means, located at the surface, for injecting the injection medium into the micro annulus.
- the injection medium may be selected from the group consisting of gas, air, or fluid.
- the well bore intersects and extends past a coal bed methane gas seam so that a sump portion of the well bore is formed.
- the apparatus is placed below the coa! bed methane gas seam in the sump portion.
- the apparatus may be placed within a well bore that intersects subterranean hydrocarbon reservoirs.
- the invention also discloses a method of drawing down a fluid column from a well bore, and wherein the well bore intersects a natural gas deposit.
- the method comprises providing a first tubular within the well bore so that a well bore annulus is formed therein, the first tubing member having an annular nozzle at a first end.
- the annular nozzle contains an annular adapter that is connected to a suction tube, and wherein the suction tube extends into an inner portion of the first tubular.
- the method includes disposing a second tubular concentrically within the first tubular so that a micro annulus is formed, and wherein a first end of the second tubular is positioned about the suction tube.
- a medium is injected into the micro annulus which in turn causes a zone of low pressure within the suction tube.
- the fluid contained within the well bore ann ⁇ lus is suctioned into the suction tube.
- the fluid is exited from the suction tube into an inner portion of the second tubular, and wherein the fluid is mixed with the medium in the inner portion of the second tubular.
- the fluids, solids and medium are then discharged at the surface.
- the method may further comprise injecting the medium into the well bore annuius and mixing the medium with the fluid within the well bore annulus. Then, the medium and fluid is forced into the suction tube,
- the method may also include lowering the level of the fluid within the well bore annulus, and flowing the natural gas into the well bore annuius once the fluid ievei reaches a predetermined Ievei.
- the natural gas in the well bore annulus can then be produced to a surface collection facility, in another preferred embodiment, a portion of the medium is jetted from the micro annulus into the wel! bore annulus, and the medium portion is mixed with the fluid within the well bore annulus. The medium and fluid is forced into the suction tube. The level of the fluid within the well bore annulus is lowered. The injection of the medium into the micro annulus is terminated once the fluid level reaches a predetermined ievei. The natural gas can then be produced into the well bore annulus which in turn will be produced to a surface collection facility.
- the well bore contains a sump area below the level of the natural gas deposit and wherein the suction member is positioned within the sump area.
- the natural gas deposit may be a coai bed methane seam, or alternately, a subterranean hydrocarbon reservoir.
- an apparatus for suctioning fluids and solids from a well bore includes a first tubular member disposed within the well bore forming a well bore annulus therein.
- the first tubular member has a first end and an inner portion.
- the apparatus also includes a suction tube having an inner portion with an unobstructed circular flow area for passage of the fluids and solids within the well bore annulus. an outer portion, an internal section, and an external section.
- the internal section of the suction tube extends into the inner portion of the first tubular member.
- the external section of the suction tube extends external of the first tubular member within a restricted section of the wel! bore.
- the apparatus also includes a second tubular member concentrically disposed within the first tubular member forming a micro annulus therein for injection of a power fluid.
- the second tubular member has a first end and an inner portion. The first end of the second tubular member is concentrically positioned about the outer portion of the suction tube at the internal section thereof forming an annular passage within the inner portion of the second tubular member for passage of the power fluid.
- the external section of the suction tube has an outer diameter in the range of 2 inches to 4 inches or smaller or larger.
- the external section of the suction tube has a length in the range of 1500 feet to 3000 feet or shorter or longer.
- the suction tube may comprise a plurality of tube segments threadedly connected together.
- the restricted section of the well bore is formed by a casing liner affixed within the well bore, an open hole wel! bore smaller than the outside diameter of the first tubular member, or multiple well bores smaller than the OD of the first tubular member.
- the apparatus may further include an annular adapter having an outer wall and an inner wall.
- the outer wall of the annular adapter may be threadedly connected to the first end of the first tubular member.
- the inner wall of the annular adapter may be threadedly connected to the suction tube at the internal section thereof.
- the apparatus may also include a stabilizer means disposed about the second tubing member.
- the stabilizer means stabilizes the second tubing member within the first tubing member
- the apparatus may include a jet means disposed within the first tubular member.
- the jet means delivers an injected power fluid from the micro annulus into the well bore annulus,
- the apparatus may further include an inner tubing restriction sleeve disposed within the second tubular member, A portion of the internal section of the suction tube extends into the inner tubing restriction sleeve,
- the apparatus may also include an injection means.
- the injection means may be located at the well-bore surface for injecting the power fluid into the micro annulus.
- the power fluid may be a gas, air, or a liquid.
- An alternative embodiment of the method of the present invention involves drawing down fluids and solids in a well bore.
- the well bore intersects a hydrocarbon deposit having a hydrocarbon, e.g., a natural gas or oil deposit having natural gas or oil.
- the alternative method includes the step of providing an assembly comprising: a first tubular member, the first tubular member having a first end and an inner portion; a suction tube having an inner portion with an unobstructed circular flow area for passage of the fluids and solids within a well bore annulus, an outer portion, an internal section, and an external section, the internal section of the suction tube extending into the inner portion of the first tubular member, the external section of the suction tube extending external of the first tubular member.
- the alternative method includes the step of disposing the assembly within the well bore.
- the first tubular member forms the well bore annulus in the well bore when disposed therein.
- the externa! section of the suction tube extends within a restricted section of the well bore.
- the alternative method includes the step of disposing a second tubular member concentrically within the first tubular member forming a micro annulus therein for injection of a power fluid.
- the second tubular member has a first end and an inner portion.
- the first end of the second tubular member is concentrically positioned about the outer portion of the suction tube at the internal section thereof forming an annular passage within the inner portion of the second tubular member for passage of the power fluid.
- the alternative method also includes injecting the power fluid into the micro annulus.
- the alternative method further includes channeling the power fluid through the annular passage.
- the alternative method includes causing an area of low pressure within the suction rube and drawing down the fluids and solids contained within the well bore annulus (and in the well bore containing the casing liner) into the suction tube.
- the alternative method includes discharging the fluids and solids from the suction tube into the inner portion of the second tubular member and mixing the fluids and solids with the power fluid in the inner portion of the second tubular member.
- the alternative method includes discharging the mixture of the fluids, solids, and power fluid at a surface of the well bore.
- the alternative method may include the additional steps of flowing the hydrocarbon from the hydrocarbon deposit (e.g.. natural gas or oil from the natural gas or oil deposit) into the wei! bore annulus once a level of the fluids and solids in the well bore annulus is reduced to a predetermined level and producing the hydrocarbon (e.g., natural gas or oil) in the well bore annulus to a surface collection facility.
- the hydrocarbon deposit e.g.. natural gas or oil from the natural gas or oil deposit
- the external section of the suction tube has an outer diameter in the range of 2 inches to 4 inches or smaller or larger.
- the external section of the suction tube has a length in the range of 1500 feet to 3000 feet or shorter or longer.
- the suction tube may comprise a plurality of tube segments threaded iy connected together.
- the restricted section of the well bore is formed by a casing liner affixed within the well bore, an open hole well bore smaller than the outside diameter of the first tubular member, or multiple well bores smaller than the OD of the first tubular member.
- the well bore contains a sump area below a level of the hydrocarbon deposit (e.g., natural gas or oil deposit) and a portion of the external section of the suction tube is positioned within the sump area.
- the hydrocarbon deposit may be a natural gas or oil deposit and more particularly a coal-bed-methane seam or other hydrocarbon seam.
- the power fluid may be a gas, air, or a liquid.
- An advantage of the present invention is the novel annular nozzle. Another advantage of the present invention includes the apparatus herein disclosed has no moving parts. Another advantage is that the apparatus and method will draw down fluid levels within a well bore. Another advantage is that the apparatus and method will allow depletion of low pressure wells, or wells that have ceased production due to insufficient in-situ pressure, and/or pressure depletion.
- the apparatus and method provides for the suctioning of fluids and solids. Another advantage is it can be run in vertical, directional, or horizontal well bores. Another advantage is a wide range of suction discharge can be implemented by varying medium injection rates. Another advantage is that the device can suction from the well bore both fluids as well as solids.
- a feature of the present invention is that the annular nozzle provides for an annular flow area for the power fluid.
- the annular nozzle includes an annular adapter and suction tube and wherein the annular adapter is attached to a tubular member, with the annular adapter extending to the suction tube.
- Another feature is use of a restriction adapter sleeve disposed on an inner portion of a second tubular member. Yet another feature is that the restriction sleeve may be retrievable.
- Another feature includes use of jets that are placed within the outer tubular member to deliver an injection medium to the well bore annuius. Yet another feature is that the jets can be placed in various positions and directed to aid in evacuating the well bore annuius. Still yet another feature is that the suction tube may contain a check valve to prevent a back flow of fluid and/or solids.
- a feature of the alternative embodiment of the present invention is the ability to operate within a well bore having a restricted ID (inner diameter).
- An additional feature of the alternative embodiment of the present invention is the capability to operate (e.g., create a suction) below a position where the medium injection pressure exceeds the maximum surface injection pressure.
- FIG. 1 depicts a first tubular member with suction member disposed within a well bore.
- FIG. 2 depicts a second tubular member having been concentrically disposed within the first tubular member of FIG, 1.
- FIG. 3 depicts a second embodiment of the apparatus illustrated in FIG. 2.
- FIG. 4 depicts the embodiment illustrated in FIG. 3 with flow lines to depict the flow pattern within the draw-down pump and from the well bore.
- FIG. 5 is a schematic illustration of the apparatus of the present invention in use in a well bore.
- FIG. 6 is a cross sectional view of the apparatus taken from line 6-6 of FIG, 4.
- FIG. 7 depicts an alternative embodiment of the apparatus of the present invention.
- FIG. 8 depicts the alternative embodiment illustrated in FlG. 7 with flow lines to depict the flow pattern within the draw-down pump and from the well bore.
- FIG. 9 is a schematic iliustration of the alternative embodiment of the apparatus of the present invention in use in a well bore.
- a first tubular member 2 is shown concentrically disposed into a well bore 4.
- a well bore can be a bore hole, casing string, or other tubular.
- the well bore 4 is a casing string.
- the first tubular member 2 has been lowered into the well bore 4 using conventional means such as by coiled tubing, work string, drill string, etc.
- the well bore extends below the surface and will intersect various types of subterranean reservoirs and/or mineral deposits.
- the well bore is generally drilled using various types of drilling and/or boring devices, as readily understood by those of ordinary skill in the art.
- the first tubular member 2 disposed within the well bore 4 creates a well bore animlus 5.
- the well bore 4 may be a casing string cemented into place or may simply fae a drilled bore hole or other tubing. It should be noted that while a vertical well is shown in the figures, the well bore 4 may also be of deviated, directional or horizontal contour.
- the first tubular member 2 will have an annular nozzle that comprises an annular adapter and a suction tube. More specifically, the annular adapter 6 is attached to the second end 8 of the first tubular member 2.
- the annular adapter 6 contains thread means 10 that make-up with the thread means 12 of the first tubular member 2.
- the annular adapter 6 has a generally cylindrical outer surface 14 that has a generally reducing outer surface portion which in turn extends radially inward to inner portion 16.
- the inner portion 16 has thread means 18.
- the suction tube 20 will extend from the annular adapter 6. More specifically, the suction tube 20 will have thread means 22 that will cooperate with the thread means 18 in one preferred embodiment and as shown in Fig.
- the suction tube 20 has a generally cylindrical surface 24 that then extends to a conical surface 26, which in turn terminates at the orifice 28.
- the orifice 28 can be sized for the pressure draw down desired by the operator at that point.
- the suction tube has an inner portion 29. Note that Fig. 1 shows the opening 72 of the annular adapter 6.
- FIG. 1 further depicts a plurality of jets. More specifically, the jet 30 and jet 32 are disposed through the first tubular member 2. The jets 30, 32 are positioned so to direct a stream into the well bore annulus 3. The jets are of nozzle like construction and are positioned in opposite flow directions, at different angles, and it is also possible to place the jets in different areas on member 2 in order to aid in stirring the fluid and solids within the well bore annulus. Jets are usually sized small in order to take minimal flow from the micro annulus (as described below).
- a second tubular member 34 is shown having been concentrically disposed within the first tubular member 2 of FIG. 1.
- the second tubular member 34 will have stabilizer means 36 and 38.
- the stabilizer means 36, 38 may be attached to the outer portion of the second tubular member 34 by conventional means such as by welding, threads, etc.
- the stabilizer means may be a separate module within the second tubular member 34.
- three stabilizer means are disposed about the outer portion of the second tubular member 34. As shown in FIG. 2, the stabilizer means are attached to the second tubular member 34.
- the stabilizer means 36, 38 can be placed on the second tubular member 34 at any position, direction and/or angle needed to stabilize second tubular member 34 over suction tube 20.
- a micro annulus 40 is formed.
- the second tubular member 34 is placed so that the suction tube 20 extends past an end 42 of the second tubular member 34.
- a medium is injected into the micro annuius 40, and wherein the medium will be directed about the end 42 into the passage 44 and up into the inner diameter portion 46 of the second tubular member 34.
- the passage 44 is formed from the suction tube being disposed within the second tubular member 34, The passage 44 represents an annular flow area of the annuiar nozzle that the medium traverses through.
- FIG. 3 also shows two additional jets, namely jet 50 and jet 52.
- the jets are of nozzle like construction.
- the jets may be placed in varying positions and/or angle orientation in order to lift the well bore fluids and solids to the surface. The position and/or angle orientation of the jets is dependent on specific well bore configurations, flow characteristics, and other design characteristics.
- the jets 50, 52 are positioned to direct a portion of the micro annulus injection medium exiting the jets 50. 52 into the bottom of the suction tube 20.
- the inner tubing restriction sleeve 48 has an outer diameter portion 54 that will cooperate with the inner diameter portion 46 of the second tubular member 34. Extending radially inward, the sleeve 48 has a first chamfered surface 56 that extends to an inner surface 58 which in turn extends to conical surface 60. The conical surface 60 then stretches to radial surface 62 which in turn extends to the conical surface 64 which then stretches to the radial surface 66.
- FIG. 3 further depicts thread means 68 on the restriction sleeve 48 that will cooperate with thread means 70 on the second tubular member 34 for connection of the restriction sleeve 48 to the second tubular member 34.
- the inner diameter portion of the restriction sleeve 48 can vary in size according to the various needs of a specific application. In other words, the inner diameter of the restriction sleeve 48 can be sized based on the individual well needs such as down-hole pressure, fluid density, solids content, etc.
- the passage 44 is formed between the restriction sleeve 48 and the suction tube 20.
- FIG. 4 depicts the embodiment illustrated in FIG. 3 with flow lines to depict the flow pattern within the draw-down pump and from well bore 4,
- the operator would inject a medium, such as gas, air, or fluid, into the micro annul us 40.
- the medium will generally be injected from the surface.
- the medium sometimes referred to as a power fluid, proceeds down the micro annuhis 40 (as seen by the arrow labeled "A") and into the annular nozzle. More specifically, the medium will flow around the end 42 and in turn into the passage 44 (see arrow "B"). Due to the suction tube 20 as well as the restriction sleeve 48, the flow area for the injected medium has been decreased.
- This restriction in flow area will in turn cause an increase in the velocity of the medium within the passage 44.
- a further restriction is experienced once the medium flows past the conical surface 64 (see arrow "C"), and accordingly, the velocity again increases.
- the velocities within the passage 44 and immediately above the orifice 28 would have also increased.
- the pressure within the suction tube 20, however, will be experiencing suction due to the venturi effect.
- the pressure Pl is greater than the pressure at P2 which causes flow into, and out of, the suction tube 20.
- the orifice 28 and/or restriction sleeve 48 can be sized to create the desired pressure draw down.
- the fluid and solids contained within the well bore annuius 5 will be suctioned into the suction tube 20 via opening 72.
- the suction thus created will be strong enough to suction fluids and solids contained within the well bore annulus 5 (see arrow "D").
- the fluid and solids Once the fluid and solids exit the orifice 28, the fluid and solids will mix and become entrained with the medium within the throat area denoted by the letter "T" and will be carried to the surface together with the injection media.
- the jets 30, 32 will also take a portion of the medium injected into the micro annulus 40 and direct the medium into the well bore annuius 5. This will aid in mixing and moving the fluid and solids within the well bore annulus 5 into the suction tube 20.
- FIG. 4 also depicts the jets 50, 52 that will direct the medium that has been injected into the micro annulus into the suction tube 20. Again, this will aid in stirring the annular fluid and solids, and causing suction at the opening 72 and aid in directing the fluid and/or solids into the suction tube 20.
- the invention may include placement of an auger type of device (not shown) which would be operatively associated with the annular adapter 6. The auger means would revolve in response to the circulation of the medium which in turn would mix and crush the solids.
- the well bore 4 intersects a natural gas deposit.
- the natural gas deposit is a coal bed methane seam.
- a bore hole 74 is drilled extending from the well bore 4, As shown in FlG. 5, the bore hole 74 is essentially horizontal, and the bore hole 74 may be referred to as a drainage bore hole 74.
- the methane gas embedded within the coal bed methane seam will migrate, first, to the drilled bore hole 74 and then, secondly, into the well bore 4.
- the natural gas deposit may be a subterranean hydrocarbon reservoir.
- the natural gas deposit is a subterranean hydrocarbon reservoir, there is no requirement to drill a drainage bore hole.
- the in-siiu hydrocarbons will flow into the well bore annulus 5 due to the permeability of the reservoir.
- the invention herein described can be used in coal bed methane seams as well as traditional oil and gas subterranean reservoirs.
- the annular adapter 6 is shown attached to the first tubular member 2.
- the suction tube 20 extends into the second tubular member 34 and inner tubing restriction sleeve 48 as previously noted.
- the medium is injected from the surface from a generator means 76 such as a fluid pump or compressor means.
- the medium is forced (directed) down the well bore 4.
- the medium flowing through the annular nozzle will in turn cause suction within the opening 72 so that the fluid and solids that have entered into the well bore 4 can be withdrawn.
- the fluid and solids that enter into the inner portion 46 of the second tubular member 34 will be delivered to separator means 78 on the surface for separation and retention.
- separator means 78 As the fluid is drawn down to a sufficient level within the well bore 4, gas can migrate from the natural gas deposit into the well bore 4. The gas can then be produced to the surface (via well bore annulus 5 ⁇ to production facility means 79 for storage, transportation, sale, etc.
- the well bore 4 contains a sump area 80.
- the sump area 80 can collect the fluid and solids which in turn will be suctioned from the well bore 4 with the novel apparatus herein disclosed.
- the fluid level is drawn down thereby allowing the gas from the deposit to enter into the well bore 4 for production to the surface. If the subterranean mineral deposit is pressure deficient or is subject to water encroachment, then water may migrate back into the well bore, and into the sump. The water level can rise within the wel! bore 4, thereby reducing or shutting-off gas production.
- the fluid level can be drawn down using the suction method and apparatus herein disclosed, and production can be restored.
- the pump can continuously run to maintain a certain fluid height within well bore 4 that will aliow a certain gas production rate. This can be repeated indefinitely or until the subterranean mineral deposit is depleted.
- FIG. 6 is a cross sectional view of the apparatus taken from line 6-6 of F ⁇ G. 4.
- the well bore annulus 5 is shown.
- the micro annulus 40 is shown, and as previously described, the medium (power fluid) is injected down the micro annulus.
- FIG. 6 also shows the passage 44, which is formed due to the configuration of the annular nozzle, and wherein the passage 44 represents an annular flow area for passage of the power fluid.
- the suction tube's inner portion is seen at 29 and wherein the fluid and solids being suctioned into the suction tube's inner portion 29 is being drawn from the well bore annulus 5.
- a stream that exits a restriction will have considerable kinetic energy associated therewith, and wherein the kinetic energy results from a pressure drop generated by the restriction.
- the sizing of the restriction determines the pressure drop, and a desired pressure drop can be caused by varying the size of passage 44. This can be accomplished by varying the diameter of the restriction sleeve which reduces flow area, increase velocity and in turn affects a pressure drop.
- a portion of FIG. 6 depicts the flow area created due to placement of the restriction sleeve 48.
- the restriction sleeve 48 inner diameter portion is enlarged, then the effective area of the passage 44 would be reduced thereby increasing the pressure drop.
- the size of the suction tube 20 walls could be enlarged, thereby reducing the effective flow area which in turn would cause an increase pressure drop.
- the embodiments of the apparatus of the present invention described above are drawn to a downhoie draw-down pump with a reverse jet venturi design to be used in vertical, directional, and horizontal well bores.
- the purpose of the apparatus is to provide a mechanical means powered at the surface to create a pressure drop at the bottom of the apparatus (e.g., within tubular member 2) that causes suction inside wel! bore 4.
- the suction lifts production fluids and formation fines (e.g., solids) to the surface via the power fluid used at the surface to power the pressure drop created at the bottom of the apparatus.
- the apparatus is operational in a well bore having an ID (inner diameter) that exceeds the OD ⁇ outer diameter) of the apparatus (e.g.. the OD of tubular member 2).
- the apparatus can only be run downhole to a position directly above the start o the casing liner where the restriction begins.
- the apparatus cannot be run within the casing liner because the OD of the apparatus exceeds the ID of the casing liner.
- the apparatus can only be run down the well bore to a position where the down-hole pressure does not exceed the maximum injection pressure of the surface equipment providing the power or drive fluid.
- the alternative embodiment of the apparatus of the present invention shown in FIG. 7 is able to operate within a well bore having a restricted ID.
- the alternative apparatus is further able to operate below a position where the pressure exceeds the maximum injection pressure.
- the alternative embodiment may include suction tube 20 having an internal section 81 and an external section 82.
- Section 82 extends longitudinally from bottom 84 of adapter 6.
- section 82 of tube 20 extends downhole within casing liner 86.
- Section 82 extends the pressure drop and suction of the apparatus within well bore 4 from bottom 84 of adapter 6 (or second end 8 of first tubular member 2) to inlet 90 of tube 20.
- Section 82 may be comprised of two or more tubular segments or sections threadedly connected together.
- the OD of section 82 may vary.
- the OD of section 82 may be in the range of 2" to 4" or from 2 3/8" to 2 V 3 " or smaller or larger.
- the length of section 82 may also vary.
- section 82 may have a length in the range of 1500 feet to 3500 feet or shorter or larger.
- an operator can create the pressure drop inside the apparatus at any compatible well bore minimum ID depth.
- the alternative embodiment aiso alleviates any injection pressure problems by setting tubular member 2 at an acceptable injection pressure depth and by letting section 82 extend the pressure drop and suction deeper into well bore 4. such as for example, within casing liner 86.
- FIG, 8 depicts the alternative embodiment illustrated in FIG. 7 with flow lines to depict the flow pattern within well bore 4.
- the operator would inject a medium, such as gas. air, or liquid, into micro annukis 40.
- the medium will generally be injected from the surface.
- the medium or power fluid proceeds down micro annulus 40 (as seen by the arrow labeled "'A") and into the annular nozzle. More specifically, the medium will flow around end 42 and in turn into passage 44 (see arrow % 'B").
- the suction will be strong enough to suction fluids and solids contained within well bore annulus 5 (and in well bore 92 within casing liner 86) (see arrow " 4 D"). Once the fluids and solids exit orifice 28, the fluids and solids will mix and become entrained with the medium or power fluid within the throat area denoted by the letter "T' ' and will be carried to the surface.
- Jets 30, 32 are not required but if provided will also take a portion of the medium injected into micro annulus 40 and direct the medium into well bore annulus 5. This will aid in mixing and moving the fluids and solids within well bore annulus 5 (and well bore 92 within casing liner 86) and into suction tube 20. It is possible to place a check valve (not shown) within suction tube 20. The check valve would prevent the fluids and solids from falling back down. Also, it is possible to make restriction sleeve 48 retrievable so that restriction sleeve 48 could be replaced due to the need for a more appropriate size, wear, and/or general maintenance. Moreover, the alternative embodiment may include an auger type device (not shown), which would be operatively associated with annular adapter 6. The auger device would revolve in response to the circulation of the medium which in turn would mix and crush the solids.
- FIG. 9 is a schematic illustration of the alternative embodiment of the apparatus of the present invention in use in well bore 4 that includes casing liner 86.
- Well bore 4 intersects a natural gas deposit, which as shown in FIG. 9, is a coal-bed methane seam,
- a coal-bed methane seam bore hole 74 is drilled extending from well bore 4.
- bore hole 74 is essentially horizontal, Bore hole 74 may be referred to as drainage bore hole 74.
- the methane gas embedded within the coal-bed methane seam will migrate. The gas first migrates to drilled bore hole 74. The gas then migrates into well bore 4 (which extends into well bore 92 within casing liner 86).
- the natural gas deposit may be a subterranean hydrocarbon reservoir.
- the alternative embodiment may therefore be used in coai-bed methane seams as well as traditional oil and gas subterranean reservoirs.
- there is no need to drill a drainage bore hole for a subterranean hydrocarbon reservoir as the in-situ hydrocarbons will flow into well bore annulus 5 due to the permeability of the reservoir.
- first tubular member 2 including annular adapter 6 and suction tube 20
- second tubular member 34 have been lowered into well bore 4 to a position where end 84 of adapter 6 is positioned within well bore 4 directly above the start of casing liner 86 which has a reduced or restricted ID as compared to the ID of well bore 4.
- Suction tube 20 has section 82, which extends downhole within casing liner 86.
- the medium is injected from the surface from generator means 76, e.g., a fluid pump or compressor means.
- the medium is forced (directed) down well bore 4.
- the medium flowing through the annular nozzle will cause suction within opening 90 of suction tube 20 so that the fluids and solids that have entered into well bore 4 (and within well bore 92 within casing liner 86) can be withdrawn.
- the fluids and solids that enter into inner portion 46 of second tubular member 34 will be delivered to separator means 78 on the surface for separation and retention.
- separator means 78 As the fluids and solids are drawn down to a sufficient level within well bore 4, gas can migrate from the natural gas deposit into well bore 4. The gas can then be produced to the surface (via well bore annulus 5) to production facility means 79 for storage, transportation, sale, etc.
- the alternative embodiment may be used in well bores that have smaller ID casing liners placed deeper inside the well bore.
- An example of such use would be the following configured well bore: ⁇ 7 5/8" production casing from 0 ft. to 4000 ft with ID of 6 %"
- the apparatus would be configured as follows:
- tubular member 2 would have an OD of 5 1/2" from 0 ft. to 3940 ft
- section 82 of suction tube 20 would have an OD of 3 Vi" or as small as 2 3/8" and extend from 3940 ft. to 6000 ft.
- the pressure drop and suction would be created inside of the apparatus at 3940 ft.
- the suction would be transmitted through suction tube 20 to outlet 90 at 6000 ft.
- Production fluid and formation fines would be sucked from 6000 ft. through suction tube 20 to tubular member 2 at 3940 ft.
- the well bore could be a vertical, directional, or horizontal well bore,
- the well bore may be configured as follows: ⁇ 7 5/8" production casing from 0 ft. to 4000 ft with ID of 6 3 A" ⁇ 5 VT liner from 3950 ft. to 5000 ft. with ID of 4 3 Z 4 " ⁇ 4 %" open hole from 5000 ft. to 6000 ft with ID of 4 W
- the apparatus would be configured as follows:
- tubular member 2 would have an OD of 5 1/2" from 0 ft. to 3940 ft.
- ® section 82 of suction tube 20 would have an OD of 3 i4" or as small as 2 3/8"' and extend from 3940 ft. to 6000 ft.
- the pressure drop and suction would be created inside of the apparatus at 3940 ft.
- the suction would be transmitted through suction tube 20 to outlet 90 at 6000 ft.
- Production fluids and formation fines would be sucked from 6000 ft. through suction tube 20 to tubular member 2 at 3940 ft.
- the well bore could be a vertical, directional, or horizontal well bore.
- well bore 4 could be configured as follows:
- tubular member 2 cannot be run to a depth that would create pressure greater than 2500 psi, e.g., 5000 ft.
- the apparatus (without section 82) could only be run to a depth of 5000 ft. With the well bore configured as described, the apparatus (with section 82) would be configured as follows:
- tubular member 2 would have an OD of 5 I /2" from 0 ft. to 5000 ft.
- section 82 of suction tube 20 would have an OD of 3 1 Za" or as small as 2 3/8" and extend from 5000 ft. to 7000 ft.
- the acceptable pressure drop and suction would be created inside of the apparatus at 5000 ft.
- the suction would be transmitted through suction tube 20 to outlet 90 at 7000 ft.
- Production fluids and formation fines would be sucked from 7000 ft. through suction tube 20 to tubular member 2 at 5000 ft.
- the apparatus as so configured would keep the injection pressures at 2500 psi maximum required by the surface equipment.
- the well bore could be a vertical, directional, or horizontal well bore.
Abstract
Description
Claims
Applications Claiming Priority (2)
Application Number | Priority Date | Filing Date | Title |
---|---|---|---|
US12/423,438 US8118103B2 (en) | 2003-09-10 | 2009-04-14 | Downhole draw-down pump and method |
PCT/US2010/027503 WO2010120424A1 (en) | 2009-04-14 | 2010-03-16 | Downhole draw-down pump and method |
Publications (2)
Publication Number | Publication Date |
---|---|
EP2419602A1 true EP2419602A1 (en) | 2012-02-22 |
EP2419602A4 EP2419602A4 (en) | 2017-07-12 |
Family
ID=42982782
Family Applications (1)
Application Number | Title | Priority Date | Filing Date |
---|---|---|---|
EP10764800.8A Withdrawn EP2419602A4 (en) | 2009-04-14 | 2010-03-16 | Downhole draw-down pump and method |
Country Status (4)
Country | Link |
---|---|
US (3) | US8118103B2 (en) |
EP (1) | EP2419602A4 (en) |
CA (1) | CA2764281C (en) |
WO (1) | WO2010120424A1 (en) |
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CN104500007B (en) * | 2014-12-31 | 2018-03-13 | 山东威马泵业股份有限公司 | Gas can force the method and apparatus for lifting water or oil |
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- 2009-04-14 US US12/423,438 patent/US8118103B2/en active Active
-
2010
- 2010-03-16 EP EP10764800.8A patent/EP2419602A4/en not_active Withdrawn
- 2010-03-16 WO PCT/US2010/027503 patent/WO2010120424A1/en active Application Filing
- 2010-03-16 CA CA2764281A patent/CA2764281C/en active Active
-
2011
- 2011-11-07 US US13/290,332 patent/US20120048569A1/en not_active Abandoned
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2013
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Also Published As
Publication number | Publication date |
---|---|
EP2419602A4 (en) | 2017-07-12 |
US20090194294A1 (en) | 2009-08-06 |
CA2764281A1 (en) | 2010-10-21 |
US20120048569A1 (en) | 2012-03-01 |
WO2010120424A1 (en) | 2010-10-21 |
CA2764281C (en) | 2016-05-31 |
US8118103B2 (en) | 2012-02-21 |
US20130264067A1 (en) | 2013-10-10 |
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